Reservoir Fluids Solutions

Custom reservoir fluid solutionsOur reservoir fluid solutions help prepare, repair, cleanout and complete the wellbore. Additional care is taken with each solution to ensure it has been engineered and then customized to minimize damage to the producing zone.

Maximize your well production or injectionProducing zones are the reason you drill—and these zones need all the care and attention that a custom reservoir fluid solution can provide. Realizing that a drilling fluid could damage a reservoir’s productivity, Baroid pioneered the study of reservoir drilling. Today our solutions not only preserve the reservoir’s innate permeability, but our solutions can actually enhance productivity to the core’s native potential.

Increase your completion efficiencyAn unclean wellbore leads to completion failures and re-runs—all of which take up valuable rig time and lead to a higher well construction bill. That’s why we believe that the efficient completion of your well starts with effective wellbore clean-up and displacement. After displacement, Baroid leverages a variety of reservoir fluid solutions to ensure the best possible scenario for your completion.

Assurance of resultsAt Baroid, all of our processes are interlinked and work together to make our approach unique. They ensure consistent and reliable delivery of customized solutions around the world. Rigorous adherence to our process helps to manage risk and improve safety.

An operator in the U.K. was using a competitor’s breaker system for well completions, resulting in an average formation-damage skin factor of 5.5.
The operator challenged Baroid for a better solution to minimize the formation damage and differential sticking potential in a 2,100-foot (640-meter) length of an 8.5-
inch x 9.5-inch horizontal section while maintaining the equivalent circulating density (ECD) within a 13.5-lb/gal.

In India, Oil and Natural Gas Corporation Ltd.
(ONGC) was involved in the development of a
high-pressure/high-temperature (HPHT) field in the
western Mumbai Offshore Basin. Many of these
wells could not be tested to their full potential due
to lack of an appropriate and cost-effective HPHT
completion fluid. Downhole temperatures were as
high as 400ºF (204°C), and densities as high as 17.5 lb/gal (2.1 SG) were required.

During well planning the customer decided to extend the
well’s horizontal reservoir section from 17,751 ft (5,411
meters) to 27,751 ft (8,459 meters), with a lateral section
of 18,674 ft (5,692 meters). This operation was the first
time the customer had combined two reservoir intervals,
and it involved running and installing the longest liner
section in the UAE at the time: 18,824 ft (5,738 meters)
of a 6-5/8-inch slotted liner.